Generation



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|FLORIDA POWER & LIGHT |

|COMPANY – New England Division |

|(FPL-NED) |

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|Facility Connection Requirements |

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May 1, 2005

FPL-NED Facility Connection Requirements

Table of Contents

I. COMMON REQUIREMENTS Page Number

A. Responsibilities 2

B. Site Access 2

C. Safety 2

D. Operations 3

E. Control Areas 3

F. Responsibilities during Emergency Conditions 3

G. Maintenance of Facilities 3

H. Point of Interconnection 4

I. Transmission Line Configurations 4

J. Grounding 5

K. Insulation Coordination 6

L. Structures 6

M. Ratings 6

N. Reliability and System Security 7

O. Protective Relaying 7

P. Metering 9

Q. SCADA 9

R. Ferroresonance 9

S. Future Modifications 9

T. Coordination of Impact Assessments 10

II. GENERATION

A. Applicability 10

B. Process 10

C. Configuration 10

D. Operations & Safety 10

E. Generator Protection Requirements 11

F. Support of the Grid 12

G. Generator Testing 13

H. Power Factor 13

I. Interrupting Ratings 13

J. Source System Grounding 14

K. Generator Data 14

L. Generator Telemetry 15

III. TRANSMISSION

A. Applicability 15

B. Process 15

C. Configuration 16

D. Operations and Safety 16

E. Metering 16

F. Protection 16

G. Transmission Reclosing 17

H. Reactive Power Control 17

I. Unbalanced Phases 17

J. Delivery Point Power Factor 17

K. Delivery Point Power Quality 17

L. Delivery Point Metering 18

M. Delivery Point Auto-Restoration 18

N. Delivery Point Load Shedding Programs 18

O. Delivery Point Generation 18

P. Delivery Point Parallel Operation 18

APPENDIX 1 Generator Data Requirements

APPENDIX 2 Procedures for Notification of Generating Plant Operational Data

And Control Status

This document has been prepared to identify the technical requirements for connecting new facilities to the FPL-NED transmission system. It applies to new connections or substantial modifications of existing generating units or transmission interconnections as well as existing and new end user delivery points. Rather than give detailed technical specifications this document provides a general overview of the functional objectives and requirements to be met in the design of facility connections. These requirements are written to establish a basis for maintaining reliability, power quality, and a safe environment for the general public, power consumers, maintenance personnel and the equipment. The requirements and guidelines found in this document are consistent with those used by FPL-NED when installing new FPL-NED facilities or modifying existing FPL-NED facilities. This document is written to comply with NERC Planning Standards (FAC-001-0 Facility Connection Requirements and FAC-002-0 Coordination of Plans for New Generation, Transmission and End-User Facilities) which requires entities responsible for the reliability of the interconnected transmission systems to maintain and make available a Facility Connections Requirements document These standards also require those entities seeking to add facilities or connect to the interconnected transmission system to comply with this Facility Connection Requirements document. This document is also written to describe the coordination efforts of FPL-NED with the relevant Transmission Planners and Planning Authority with regard to the assessment of the impact on the reliability of the transmission system from the addition of new generation, transmission or end-user facilities being interconnected with FPL-NED’s transmission system so as to avoid any adverse impacts from such interconnections. The NERC Planning Standards are posted on NERC’s web site (standards). The standards and technical requirements specified within this document are intended to be consistent with all applicable ISO-New England and Northeast Power Coordinating Council (NPCC) standards, rules and procedures pertaining to facility connections. This Facility Connection Requirements document is revised from time to time to reflect changes or clarifications in planning, operating, or interconnection policies.

I. COMMON REQUIREMENTS

This section addresses the technical requirements that are common to the connection of generation, transmission and delivery point facilities to the FPL-NED transmission system. General overviews of functional requirements are given in this section. This document is not intended to be a comprehensive design specification. This document references, and therefore is supported by other current, applicable industry standards. Specific design and construction of the electrical facilities are to be in accordance with these standards which include, but are not limited to the following.

NFPA 70 – NEC - National Electrical Code

NESC – National Electrical Safety Code

NEMA SG-6 – Power Switching Equipment

ASTM – American Society of Testing Material

AISC – American Institute of Steel Construction

ACI – American Concrete Institute

IEEE – Institute of Electrical and Electronic Engineers, Inc.

UL – Underwriters Laboratories, Inc.

EPA – Environmental Protective Agency

ASME – American Society of Mechanical Engineers

ASCE – American Society of Civil Engineers

NFPA – National Fire Protective Association

NRMCA – National Ready Mixed Concrete Association

CRSI – Concrete SI – Concrete Reinforcing Steel Institute

ANSI – American National Standards Institute

ICEA – Insulated Cable Engineers Association

The facility designs shall comply with all applicable federal, state and local laws and regulations. Final design of facility connections to the FPL-NED transmission system will be subject to FPL-NED review and approval on a case-by-case basis.

I. A. Responsibilities

It is the responsibility of the facility owner to provide all devices necessary to protect the customer’s equipment from damage by abnormal conditions and operations that might occur on the interconnected power system. The facility owner shall protect its generator and associated equipment from overvoltage, undervoltage, overload, short circuits (including ground fault conditions), open circuits, phase unbalance, phase reversal, surges from switching and lightning, over and under frequency conditions, and other injurious electrical conditions that may arise on the interconnected system.

It is the responsibility of the facility owner to provide for the orderly re-energization and synchronizing of their high voltage equipment to other parts of the electric system. Appropriate operating procedures and equipment designs are needed to guard against out of synch closure or uncontrolled energization. Each owner is responsible to know and follow all applicable regulations, industry guidelines, safety requirements, and accepted practice for the design, operation and maintenance of the facility.

I. B. Site Access

There are situations where some equipment that is owned by FPL-NED is located within the Customer’s facility. This is often required for data acquisition or metering. Site access is to be provided to FPL-NED employees or its other representatives where FPL-NED equipment is located within the Customer’s facility.

Interconnecting facilities shall be made available for on-site inspection for the purpose of demonstrating conformance to the requirements set forth in this document. Request for inspection will be provided in writing at least 14 days in advance.

I. C. Safety

Safety is of utmost importance. Strict adherence to established switching, tagging and grounding procedures is required at all times for the safety of personnel. Any work carried out within a facility shall be performed in accordance with all applicable laws, rules, and regulations and in compliance with Occupational Safety and Health Administration (OSHA), National Electric Safety Code (NESC) and good utility practice. Automatic and manual disconnect devices are to be provided as a means of removing all sources of current to any particular element of the power system. Only trained operators are to perform switching functions within a facility under the direction of the responsible dispatcher or designated person as outlined in the National Electric Safety Code.

I. D. Operations

Operational procedures are to be established in accordance with all applicable NRC, NESC, OSHA, Northeast Power Coordinating Council (NPCC), NERC and ISO-NE requirements. Each party shall designate operating representatives to address: lines of communications, maintenance coordination, actions to be taken after de-energization of interconnected facilities, and other required operating policies. All parties are to be provided with current station operating diagrams. Common, agreed upon nomenclature is to be used for naming stations, lines and switches. Updated diagrams are to be provided when changes occur to interconnected facilities.

The operator of facilities interconnecting to the FPL-NED transmission system will not perform any switching that energizes or denergizes portions of the FPL-NED transmission system or that may adversely affect the FPL-NED transmission system without prior notice to FPL-NED or its designated operating representative, and without prior authorization from ISO-NE, or its designated Satellite Control Center. Operators of facilities interconnecting to the FPL-NED transmission system will notify the FPL-NED, or its designated operating representative before performing any switching that would significantly affect voltages, power flows or reliability in the FPL-NED transmission system.

I. E. Control Areas

All loads, generation, and transmission facilities must be part of the ISO-NE control area, or its designated satellite, as applicable.

I. F. Responsibilities during Emergency Conditions

All control areas within the NPCC region are responsible for maintaining voltage and frequencies within agreed upon limits. All operators of facilities interconnected to the transmission systems in the NPCC Region are required to communicate and coordinate with the ISO-NE control area operator. During emergency conditions, the facility operator shall raise or lower generation, adjust reactive power, switch facilities in or out, or reduce end-user load as directed by the ISO-NE control area operator, or its designated Satellite Control Center. Within the NPCC Region, the ISO-NE has overall responsibility for the secure operation of the interconnected transmission systems. All facility owners are expected to follow all applicable NPCC and ISO-NE rules, policies, procedures and guides.

I. G. Maintenance of Facilities

The maintenance of facilities is the responsibility of the owner of those facilities. Adjoining facilities on the interconnected power system are to be maintained in accordance with accepted industry practices and procedures and with all applicable ISO-NE policies, rules, procedures. Each party is to have a documented maintenance program ensuring the proper operation of equipment. FPL-NED will have the right to review maintenance reports and calibration records of equipment that could impact the FPL-NED system if not properly maintained. FPL-NED and ISO-NE (or its designated Satellite Control Center) are to be notified as soon as practicable about any out of service equipment that might effect the protection, monitoring, or operation of interconnected facilities.

Maintenance of facilities interconnected to the FPL-NED transmission system shall be done in a manner that does not place the reliability and capability of the FPL transmission system, or other portions of the NEPOOL transmission system at risk. Planned maintenance must be coordinated and scheduled with FPL-NED and must be in accordance with ISO-NE Operating Procedure Number 3 – Transmssion Outage Scheduling.

I. H. Point of Interconnection

The point of interconnection is to be clearly described. Usually the change of facility ownership and the point of interconnection are the same point.

The voltage level, MW and MVAR capacity or demand at point of interconnection shall be compatible to, and coordinated with FPL-NED, and shall be in conformance with ISO-NE’s Operating Procedure 12 (Voltage and Reactive Requirements). The metering and communication of such metered quantities shall be in accordance with ISO-NE’s Operating Procedure 18 (Metering and Telemetering Criteria).

Metering equipment should be provided as close to the interconnection point as practicable. The interconnecting facility must be connected to the FPL-NED system through a primary interrupting device.

Facilities interconnecting to the FPL-NED transmission system must have an isolating device installed at the point of interconnection. This isolating device, typically a disconnect switch, must be capable of physically and visibly isolating the facilities from the FPL-NED transmission system. This isolating device must be lockable in the open position by FPL-NED, or its designated operating representative.

I. I. Transmission Line Configurations

Three source terminal interconnection configurations of transmission lines are to be avoided within the FPL-NED transmission system. This is due to problems associated with protective relay coverage from infeed, sequential fault clearing, outfeed or weak source conditions, reduced load flow, and automatic reclosing complications. Extensive studies are necessary to evaluate all possible implications when considering three terminal line applications.

Some new connections to the FPL-NED transmission system may require one or more FPL-NED transmission circuits to be looped through the new facility. The design and ratings of the new facilities and the transmission loop into them shall not restrict the capability of the transmission circuits or impair FPL-NED contractual transmission service obligations.

Long taps to feed connected load directly tied to a transmission line are to be avoided. This presents coverage problems to the protective relay system due to infeed. Power line carrier signals can also be lost due to odd quarter wavelength sections.

Any new interconnection configuration should be designed in such a way so as to minimize the likelihood that FPL-NED would be prohibited from taking an FPL-NED transmission facility out of service for just cause. FPL-NED shall not be forced to open a transmission facility for an adjacent interconnected generator or transmission line to obtain an outage, other than during approved scheduled outage periods as such are coordinated with, and approved by ISO-NE or its designated Satellite Control Center, or in the case of an emergency. Manual switching or clearing electrical faults within the non-FPL-NED facility shall not curtail the ability of FPL-NED to transmit power or serve its customers.

Reliable station and breaker arrangements will be used when there are new or substantial modifications to existing FPL-NED substation(s). In general, transmission substations must be configured such that line and transformer, bus and circuit breaker maintenance can be performed without degrading transmission connectivity. This generally implies a breaker and a half or double breaker, double bus configuration. A ring bus may be used when a limited number of transmission lines are involved.

I. J. Grounding

Each interconnection substation must have a ground grid that solidly grounds all metallic structures and other non-energized metallic equipment. This grid and grounding system shall be designed to meet the requirements of ANSI/IEEE 80, IEEE Guide for Safety in AC Substation Grounding and ANSI/IEEE C2, National Electrical Safety Code. The transmission line overhead ground wire (OHGW) shall be connected to the substation ground grid.

If the interconnection substation is close to another substation, the two grids may be isolated or connected. Connected grids are preferred, since they are easier to connect than to isolate. If the ground grids are to be isolated, there may be no metallic ground connections between the two substation ground grids. There must also be sufficient physical separation to limit soil conduction. If the ground grids are to be interconnected, the interconnecting cables must have sufficient capacity to handle the fault currents, duration, and duty. FPL-NED must approve any connection to an FPL-NED substation ground grid.

All transmission line structures must be adequately bonded and grounded to control step and touch potential in compliance with the NESC, and to provide adequate lightning performance. All transmission lines should have a continuous ground wire, not relying on earth as the primary conductor, to transfer fault current between structures and to substations and plant switchyards. Any exceptions to a continuous ground wire shall be verified with a system study. All ground wires and bond wires must be adequately sized to handle anticipated maximum fault currents and duty without damage.

Transmission interconnections may substantially increase fault current levels at nearby substations and transmission lines. Modifications to the ground grids of existing substations and OHGWs of existing lines may be necessary. The Interconnection Study will determine if modifications are required and the scope and cost of the modifications.

I. K. Insulation Coordination

Insulation coordination is the selection of insulation strength. Insulation coordination must be done properly to ensure electrical system reliability and personnel safety. Basic Surge Level (BSLs), surge arrester, conductor spacing and gap application, substation and transmission line insulation strength, protection, and shielding shall be documented and submitted for evaluation as part of the interconnection plan.

FPL-NED’s standard is to shield substations and transmission lines from direct lightning strokes and to provide line entrance arresters at transmission line terminals. Surge arresters are also applied at major components and systems.

Interconnection facilities to be constructed in areas with salt spray contamination or other type of contamination shall be properly designed to meet or exceed the performance of facilities not in a contamination area with regard to contamination caused outages.

I. L. Structures

Transmission and substation structures for facilities connected to the FPL-NED transmission system shall be designed to meet the National Electrical Safety Code (NESC). Substation bus systems shall be designed to comply with ANSI/IEEE Standard 605, IEEE Guide for the Design of Substation Rigid-Bus Structures.

In addition, for both transmission and substation, structural load criteria shall meet all requirements as specified by “Minimum Design Loads for Buildings and Other Structures”, ANSI 7-02, published by American Society of Civil Engineers (ASCE). Proper structural category shall be determined based on ANSI 7-02, Table 1-1.

Structural strength criteria shall comply with applicable industrial standards such as “Design of Latticed Steel Transmission Structures” (ANSI 10, published by ASCE), “Manual of Steel Construction” (published by American Institute of Steel Construction Inc.), or Building Code Requirements for Structural Concrete (ACI-318, published by American Concrete Institute).

I. M. Ratings

All facility equipment ratings shall be in accordance with NEPOOL Capacity Ratings Procedure which is posted on the ISO-NE webpage.

All circuit breakers and other fault interrupting devices shall be capable of safely interrupting fault currents for any fault they may be required to interrupt. Application of circuit breakers shall be in accordance with ANSI/IEEE C37 standards.

I. N. Reliability and System Security

FPL-NED designs and operates its transmission system to meet all applicable ISO-NE, NEPOOL, NPCC and NERC Planning and Operating Standards. The planned transmission system with its expected loads and transfers must be stable and within applicable ratings for all category A, B, and C contingency scenarios[1] The effect of category D contingencies on system stability is evaluated when changes are planned in the transmission system. The design of new transmission connections should take into account and minimize, to the extent practical, the adverse consequences of category D contingencies

System and generator stability is to be maintained for normal clearing of all three phase faults. A normally cleared fault is assumed to last six cycles (0.1 seconds) for circuit elements protected by three cycle breakers. This provides approximately one cycle margin for slower than expected fault clearing. For circuit elements protected by two cycle breakers, a normally cleared fault is assumed to last five cycles.

The power system must be stable for single line to ground faults with the failure of a protection system component to operate. This includes clearing of a system fault with the simultaneous failure of a current transformer, protective relay, breaker, or communication channel. Three phase faults with the failure of a protection system component to operate are to be considered in all design alternatives with adverse consequences to system stability minimized.

FPL-NED transmission circuits are protected with primary system relays that provide no intentional time delay when clearing faults for 100% of a line. A second high-speed relay system with communications and no intentional time delay is required if a failure of the primary system can result in instability when a fault is cleared by time delay backup protection. This can be the case for an end of line fault on a short line combined with a failed relay. Likewise, two independent high-speed protection systems may be required for bus protection if backup clearing results in instability.

I. O. Protective Relaying

Utility grade, transmission level protective relays and fault clearing systems are to be provided on the interconnected power system. All protective relays should meet or exceed ANSI/IEEE Standard C37.90 and NPCC document A-5. Adjoining power systems may share a common zone of protection between two parties. Compatible relaying equipment must be used on each side of the point of ownership within a given zone of protection. The design must provide coordination for speed and sensitivity in order to maintain power system security and reliability.

All bulk transmission power systems are to have primary protective relaying that operates with no intentional time delay for 100% of the specified zone of coverage. On transmission circuits, this is accomplished through the use of a communication channel. A second high-speed protection system may be required on a line or bus.

Backup protective systems should provide additional coverage for breaker and relay failure outside the primary zone. Specific breaker failure protection schemes must always be applied at the bulk transmission level. Specific relay failure backup must also be provided. Backup systems should operate for failures on either side of an interconnection point. Time and sensitivity coordination must be maintained to prevent misoperations.

A power source for tripping and control must be provided at substations by a DC storage battery. The battery is to be sized with enough capacity to operate all tripping devices after eight hours without a charger. An undervoltage alarm must be provided for remote monitoring by the facilities owners who shall take immediate action to restore power to the protective equipment.

Mechanical and electrical logic and interlocking mechanisms are required between interconnected facilities to ensure safe and reliable operation. These include, but are not limited to, breaker and switch auxiliary contacts, undervoltage and synch-check relays, and physical locking devices.

A transfer trip is required for many installations. It is used for backup protection and islanding schemes. Fiber optics is the preferred means of communication. Power line carrier or microwave is also used. Audio tone over phone line is the least preferred method because it may not meet requirements for speed and reliability.

Entities connecting to the FPL-NED transmission system shall investigate and keep a log of all protective relay actions and misoperations as required by NPCC document B-21 required by the NRC, NERC Standards, and ISO-NE.

Entities connecting to the FPL-NED transmission system must have a maintenance program for their protection systems in accordance with NPCC document A-4. Documentation of the protection maintenance program shall be supplied to FPL-NED ISO-NE, NRC, NPCC and NERC upon request. Test reports as outlined in the maintenance program are to be made available for review by FPL-NED. At intervals described in the documented maintenance program and following any apparent malfunction of the protection equipment, the entity shall perform both calibration and functional trip tests of its protection equipment as outlined in the NPCC document A-4.

I. P. Metering

All metering and telemetering design, installations and maintenance shall be performed in accordance with ISO-NE Operating Procedures: Number 18 – Metering and Telemetry Criteria, Number 2 – Maintenance of Communications, Computers, Metering, and Computer Equipment.

Power for SCADA or metering communication equipment, if needed, is to be provided by the station battery. Office power systems and switching networks are not acceptable.

I. Q. Supervisory Control and Data Acquisition (SCADA)

All SCADA design, installations and maintenance shall be performed in accordance with ISO-NE Operating Procedures: Number 18 – Metering and Telemetry Criteria, Number 2 – Maintenance of Communications, Computers, Metering, and Computer.

Power for SCADA or metering communication equipment, if needed, is to be provided by the station battery. Office power systems and switching networks are not acceptable.

I. R. Ferroresonance

Ferroresonance occurs on the power system under certain system configurations that may damage high voltage equipment. This phenomenon is usually caused when PT’s are tied to a bus or line stub that may be energized through breakers having capacitors in parallel with the main contacts. Since interconnection facilities may contain shared equipment, such as metering PT’s and high voltage breakers, care should be used to avoid configurations that could cause ferroresonance. Where such configurations cannot be avoided, detailed studies must be performed prior to installation to ensure ferroresonance will not occur.

I. S. Future Modifications

Any changes that affect an interconnection must be reviewed in advance. These include modifications to the metering or protection scheme as well as associated settings after the interconnection project has been completed. Information about expected increased load flows or higher fault current levels due to system changes must be provided in a timely manner. Some modifications may require engineering studies and a formal review by ISO-NE pursuant to Section I.3.9 of the ISO-NE Open Access Transmission Tariff.

I.T. Coordination of Impact Assessments with ISO-NE

As a Participating Transmission Owner within the New England Regional Transmission Organization (“RTO-NE”) and signatory to the Transmission Owners Agreement and Market Participants Agreement, FPL-NED is obligated to comply with ISO-NE’s Tariff, Rules and Procedures regarding coordinating and seeking peer review and ISO-NE review and approval of its plans for the interconnection of new generation, transmission or end-user loads, as applicable. Currently, the ISO-NE’s Tariff requires all applications for connections to FPL-NED’s Pool-Transmission-Facilities (“PTF”), including new generation and transmission interconnections to apply directly to ISO-NE for such interconnections. ISO-NE then directs and coordinates the conduct of any studies that may be required to accommodate such new interconnections. As such, FPL-NED’s involvement with assessing the impacts of new interconnections is at the direction of ISO-NE which ensures a regionally coordinated effort. ISO-NE’s practice includes have all such applications and supporting study assumptions and results also reviewed by the New England Power Pool (“NEPOOL”) Reliability Committee and other NEPOOL technical task forces. This peer review and ISO-NE approval process is designed to ensure that no adverse impacts to the operability or reliability of the New England transmission system will result from such planned changes to FPL-NED’s transmission system. For new connections to FPL-NED’s non-PTF, FPL-NED will also coordinate the review, assessment and approval of ISO-NE, as required by ISO-NE, for all such non-PTF connection applications. This process of coordinating review, assessment and ISO-NE-approval of the impacts any proposed new interconnections to FPL-NED’s transmission system may have on the transmission systems within RTO-NE ensure FPL-NED’s compliance with NERC Reliability Standard FAC-002-0.

II. GENERATION

This section addresses the technical requirements for connecting new generation to the FPL-NED transmission system or substantially modifying existing generating facilities connected to the FPL-NED transmission system. General overviews of functional requirements are described in this section. Detailed, project specific requirements will be developed as part of an Interconnection Feasibility Study, System Impact Study or a Facilities Study, or are referenced in other documents such as the NERC Planning Standards, the NERC Operating Standards, the Large Generator Standard Interconnection Procedures (LGIP) and Large Generator Interconnection Agreement (LGIA) as approved by the Federal Energy Regulatory Commission (FERC) for New England as contained in Schedule 22 of the ISO-NE Open Access Transmission Tariff, and all other applicable ISO-NE policies, rules, procedures and standards. To the extent a conflict exists between the requirements for generation specified in this document and those specified in the LGIP, LGIA or other applicable ISO-NE policies, rules, procedures and standards, such LGIP, LGIA or other applicable ISO-NE policies, rules, procedures and standards shall govern.

II. A. Applicability

This section applies to all interconnections with the FPL-NED system made at 69 kV or greater where generation is installed behind the interconnection point and is capable of operating in continuous parallel with the FPL-NED transmission system.

II. B. Process

Large Generator Interconnection Process

The connection of new generating facilities to the FPL-NED transmission system or the substantial modification of existing generating facilities shall follow the procedures specified in the FERC-approved LGIP applicable to New England contained in Schedule 22 of the ISO-NE Open Access Transmission Tariff.

Transmission Request Process All requests for transmission service shall be made in accordance with the terms and conditions of the ISO-NE Open Access Transmission Tariff.

II. C. Configuration

New generating plants that are to be connected to the FPL-NED transmission system are to be designed so as to minimize the impacts of the maintenance or unplanned outages on existing facilities by said new generator and any new lines, transformers, circuit breakers, buses or other equipment related to the interconnection of such new generation. The potential adverse effects of maintenance and equipment outages must be considered in the design of the generating plant and its connection to the FPL-NED transmission system.

II. D. Operations and Safety

Operators of generating facilities must notify FPL-NED, ISO-NE and/or the designated Satellite Control Center, and obtain approval before synchronizing the facility to or disconnecting the facility from the FPL-NED transmission system. Disconnection without prior approval is permitted only when necessary to prevent injury to personnel or damage to equipment. Generators must not energize a denenergized FPL-NED transmission circuit unless such actions are directed by FPL-NED (or its designee), or ISO-NE (or its designated Satellite Control Center) or are provided for in an interconnection agreement between FPL-NED and the interconnection customer.

Each generating facility shall provide a point of contact to FPL-NED. This contact person shall have the authority and capability to operate the facility according to the instructions of FPL-NED to ensure that the reliability of the transmission system is maintained. A point of contact shall be reachable and available through telephone or other agreed upon means of communication at all times when the Facility is energized or in operation.

Generating facilities connected to FPL-NED’s transmission systems must follow all applicable NPCC, ISO-NE and NERC Operating Standards, Rules and Procedures.

II. E. Generator Protection Requirements

Generators connecting to the FPL-NED transmission system are responsible for protecting those facilities from electrical faults and other hazardous conditions. Generator interconnections must be equipped with circuit breakers or other appropriate interrupting devices to protect those facilities. The generator owner must provide and own the primary circuit breaker or other interrupting device that protects the facility and disconnects it from the FPL-NED transmission system. The primary purpose of this interrupting device is to protect the generating plant facility. A joint use circuit breaker that protects both generating unit and transmission circuit facilities as its primary function is highly discouraged.

Synchronous generators connected to the FPL-NED transmission system should be able to withstand certain temporary excursions in voltage, frequency, reactive and real power output without tripping. This is required to support the grid and avoid cascading events.

Synchronous generators shall have the generator’s protection and controls set in accordance with all applicable ISO-NE and NPCC requirements for variation in grid voltage and frequency.

Generators must be designed to remain on line for normal clearing system faults within the close proximity to the plant switchyard. Voltage may approach zero at the switchyard bus for six cycles for some types of faults. Control systems, contactors, motors and auxiliary loads that are critical to the operation of the plant must have ride through capability where needed to avoid generator tripping for close-in faults as described above. Additionally, generator protection systems such as the Load Drop Anticipator, Early Valve Actuator or Power Load Unbalance should not be designed to trip a generator for normal clearing external faults or stable swings.

It is recognized that certain circumstances may exist that necessitate the imposition of performance criteria that is considered more stringent than the default criteria specified above. Such circumstances shall be identified during the conduct of the System Impact Study or Operational Studies for each particular generator.

II. F. Support of the Grid

1. All synchronous generators connected to the FPL-NED transmission system are to be equipped with automatic voltage regulators (AVR)[2]. Generators must operate with their excitation system in the automatic voltage control mode unless otherwise approved by FPL-NED. Generating equipment owners shall maintain a log which records the date, time, duration and reason for not being in the automatic voltage control mode when operating in parallel with the FPL-NED system. Generating equipment owners shall make this log available to FPL-NED on request. Appendix 2 has additional details for reporting of AVR status and voltage schedule deviations.

2. All synchronous generators connected to the FPL-NED transmission system must maintain a network voltage or reactive power output as specified by ISO-NE. Generating equipment owners shall maintain a log which records the date, time, duration, and reason for not meeting the network voltage schedule or desired reactive power output when operating in parallel with the FPL-NED system. Generating equipment owners shall make this log available to FPL-NED on request.

3. The generator step-up and auxiliary transformer tap settings shall be coordinated with ISO-NE.

4. The AVR's control and limiting functions must coordinate with the generator's short time capabilities and protective relay settings. The generating equipment owner shall provide FPL-NED with the AVR's control and limiter settings as well as the protection settings which coordinate with AVR control and limiting functions.

5. The installation of new generating plants has the potential to aggravate existing modes of oscillation or create new modes. All new synchronous generators connected to the FPL-NED transmission system with a nameplate rating greater than 100 MVA shall be equipped with a power system stabilizer. Technical evaluations of oscillatory stability will be conducted for the interconnection of new generating plants. New generators that cause a decrease in the damping of an existing mode of oscillation or cause a poorly damped mode of oscillation will be required to operate with the power system stabilizer in service. The determination of the power system stabilizer’s control settings will be coordinated with FPL-NED and ISO-NE. Typically this coordination would be to provide FPL-NED with preliminary power system stabilizer settings prior to the stabilizer’s field commissioning tests with the final settings provided after the field commissioning tests.

Where stabilizing equipment is installed on generating equipment for the purpose of maintaining generator or transmission system stability, the generating equipment owner is responsible for maintaining the stabilizing equipment in good working order and promptly reporting to FPL-NED any problems interfering with its proper operation.

6. All new synchronous generators connected to the FPL-NED transmission system with a nameplate rating greater than 20 MVA shall be equipped with a speed/load governing control that has a speed droop characteristic in the 3 to 6% range. The preferred droop characteristic setting is 5% as this is the typical setting for generators. Notification of changes in the status of the speed/load governing controls must be provided to the FPL-NED and ISO-NE as detailed in Appendix 2.

II. G. Generator Testing

1. Prior to commercial operation, the generating equipment owner shall provide FPL-NED with open circuit, step-in voltage test results. Recording of generator terminal voltage and field voltages shall be clearly labeled so that initial and final values can be identified in physical units[3].

2. Generating equipment owners shall annually test the gross and net dependable summer and winter capability of their units. These test results shall be provided to FPL-NED and ISO-NE in accordance with all applicable rules and procedures.

3. Generating equipment owners shall test the gross and net reactive capability of their units at least every five years, or on such intervals as required by ISO-NE rules and procedures. These test results shall be provided to FPL-NED and ISO-NE.

Generating equipment owners shall test the AVR control and limit functions of their units at least every five years or on such intervals as required by ISO-NE rules and procedures. An initial test result shall be provided to FPL-NED prior to commercial operation and every five years thereafter. The initial test results shall include documentation of the settings AVR control and limit functions. Typical AVR limit functions are; maximum and minimum excitation limiters and volts per hertz limiters. Documentation of the generator protection that coordinates with these limit functions shall also be provided. Typical generator protection of this type includes overexcitition protection, loss of field protection.

II. H. Power Factor

For synchronous generators the facilities shall be designed, operated and controlled to provide reactive power requirements consistent with policies and standards of ISO-NE and the ISO-NE Tariff. Induction generators shall have static capacitors that provide magnetizing current requirements of the induction generator field consistent with policies and standards of ISO-NE.

II. I. Interrupting Ratings

AC high voltage circuit breakers are specified by operating voltage, continuous current, interrupting current, and operating time in accordance with ANSI/IEEE Standards C37 series, “Symmetrical Current Basis.” These ratings are displayed on the individual Circuit Breaker nameplate. Breakers are scheduled for replacement when they exceed 100% of ANSI C37 Guidelines.

There may be cases where adding generation will increase the available fault current above the present interrupting ratings of the existing breakers at a substation or stations. When this occurs, breaker upgrades are to be considered as part of the interconnection project. Similarly, the connection of new generators to the transmission system may increase fault current to a level which exceeds the short time rating of overhead ground wires. The rating of overhead ground wires shall be accordance with NEPOOL Capacity Ratings Procedure document which is posted on the ISO-NE webpage. If equipment ratings will be exceeded, the appropriate modifications must be performed prior to the new generation coming on line.

II. J. Source System Grounding

When various switching devices are opened on an energized circuit, its ground reference may be lost if all sources are not effectively grounded. This situation may cause overvoltages that can affect personnel safety and damage equipment. This is especially true when one phase becomes short circuited to ground. Therefore, the interconnected transmission power system is to be effectively grounded from all sources. This is defined as X0/X1< 3 and R0/X1< 1. Interconnected generators should provide for effective system grounding of the high side transmission equipment by means of a grounded high voltage transformer.

An alternative design only for sites with less than 10 MVA is available in some limited cases but requires a special Electromagnetic Transients Program (EMTP) system study to determine applicability. Under this non-preferred option the system is not grounded at the source. However, the transmission system equipment insulation level in the area must be rated to withstand the amplitude and duration of all overvoltages caused by neutral displacement. Also the source must be removed rapidly when any overvoltage condition occurs. This includes isolation of the ungrounded source for system faults simultaneously with other relaying systems within the protected zone. Since the source provides no ground fault current, relay protection devices must operate for zero current. Some switching operations may cause the loss of all remote ground sources by islanding a part of the system even under non-fault conditions. The protection scheme must also be able to quickly remove the generation under this situation before any adverse effects occur. Some form of communication with remote transmission stations is usually required in order to accomplish this.

II. K. Generator Data

The data specified in Appendix 1 (Generator Data Requirements) and Appendix 2 (Procedures for Notification of Generating Plant Operational Data and Control Status) must be supplied for all new generators connected to the FPL-NED transmission system. In some cases a partial data submittal may be acceptable for generators rated less than 20 MVA.

II. L. Generator Telemetry

All generating plants connected to the FPL-NED transmission system must meet the applicable requirements as prescribed by ISO-NE including, but not limited to, ISO-NE OP-18 (Metering and Telemetering Criteria).

TRANSMISSION

This section addresses the technical requirements for connecting new transmission lines to the FPL-NED transmission system as well as for new and existing delivery points. A utility/customer may elect to connect to FPL-NED through a “delivery point” connection or an “interconnection point” connection.

A “delivery point” is a point of connection between FPL-NED’s transmission system and another entity’s system or facilities which ultimately delivers the power to individual customers’ loads. Two characteristics may be generally used to distinguish delivery points from interconnections: i) the protective schemes of the integrated transmission system are designed to either entirely or partially suspend service to a delivery point by disconnecting a transmission facility that serves such delivery point from the transmission system; ii) power normally flows only in one direction across the delivery point (i.e., from the transmission system to the delivery point), and thus the protective schemes at the delivery point may be designed taking into account this characteristic.

An “interconnection point”, in contrast, is a point of connection between two entities’ respective transmission systems. Interconnection points are normally operated in parallel with the transmission systems such that it is possible for power to flow in either direction. Protection systems for interconnection points are designed to prevent and/or minimize the possibility of an event within one of the systems affecting or cascading into the other system.

III. A. Applicability

This section applies to all interconnections with the FPL-NED transmission system made at 69 kV or greater. This includes utility-to-utility (entity) type interconnections used for power interchanges as well as delivery point type connections used to deliver power to end-users. Subsections C through I apply mainly to transmission interconnections. Subsections J through P apply to delivery point connections. Detailed, project specific requirements will be developed as part of a System Impact Study, a Facilities Study or are referenced in other documents such as the NERC Planning Standards or the National Electrical Safety Code. All requests for transmission service shall be made in accordance with the terms and conditions of the ISO-NE Open Access Transmission Tariff.

III. B. Process

The connection of non-FPL-NED facilities to the FPL-NED transmission system should follow the Facilities Connection Process outlined in the ISO-NE Open Access Transmission Tariff. Either FPL-NED or both entities jointly will begin a System Impact Study to determine the effect of the proposed connection on the FPL-NED transmission system. If necessary, a Facilities Study will be initiated to determine the cost of the connection and all FPL-NED equipment improvement needed to accommodate the new connection.

III. C. Configuration

The interconnection point between utilities is typically through a transmission line or lines. The change of ownership is usually at a transmission line structure. The neighboring utility must have an effectively grounded transmission system. Three terminal lines are to be avoided for certain interconnections due to problems discussed in Section I.I.

III. D. Operations and Safety

Interconnections between FPL-NED's transmission system and other transmission systems are normally operated in parallel unless otherwise agreed. However, if any operating condition or circumstance creates an undue burden on the FPL-NED Transmission System, FPL-NED shall have the right to open the interconnection(s) to relieve its system of the burden imposed upon it. Prior notice will be given to the extent practical. Each party shall maintain its system and facilities so as to avoid or minimize the likelihood of disturbances which might impair or interrupt service to the customers of the other party.

The FPL-NED and ISO-NE shall be notified prior to any maintenance work on a transmission interconnection. FPL-NED switching and safety procedures shall be strictly adhered to when maintenance is being performed on an interconnection.

III. E. Metering

Metering equipment may be located at either end of the transmission line but should be installed at the station closest to the change of ownership. Metering shall be designed and installed in accordance with ISO-NE policies, rules, procedures and standards, including but not limited to ISO-NE OP-18 (Metering and Telemetering Criteria).

III. F. Protection

The relay protection criteria under Section I is to be adhered to for utility-to-utility interconnections. When distribution load stations are looped on a transmission line, special consideration must be applied. Directional comparison blocking schemes are preferred. If permissive overreaching transfer trip (POTT) is used with fiber, the communications echo feature must be employed. This is required to ensure high-speed fault clearing when the line is open at a distribution station between the transmission terminals.

When ground distance relaying is used on short lines, the quadrilateral characteristic is to be used to provide adequate coverage for fault resistance.

Directional ground overcurrent protection should only be used after cafefull study on lines that have considerable mutual coupling with other circuits. Sensitive instantaneous directional ground overcurrent relays can cause false operation on circuits with looped distribution load stations due to switch pole asynchronism and should be avoided in such cases.

III. G. Transmission Reclosing

Automatic reclosing on interconnected transmission lines between utilities is handled based on ISO-NE policies and standards. High speed automatic reclosing must be avoided at generation substations.

III. H. Reactive Power Control

Entities interconnecting their transmission system with FPL-NED's transmission system shall comply with applicable ISO-NE policies, rules, procedures and standards, and the ISO-NE Tariff.

III. I. Unbalance Phases

Unbalance currents and voltage are to be controlled by each party on their respective side of the interconnection. However, it should be realized that switching devices, such as breakers and switches, are three phase devices and can fail with only one or two poles closed. It is the responsibility of the facility owner to protect their own equipment such as generators or transformers from damaging negative sequence currents or voltage.

III. J. End-User (Delivery Point) Power Factor

Delivery point connections to the FPL-NED transmission system shall meet the power factor requirements set forth in FPL-NED’s Schedule 21 of the ISO-NE Open Access Transmission Tariff, and shall be in conformance with all applicable provisions of ISO-NE OP-12 (Voltage and Reactive Requirements).

III. K. End-User (Delivery Point) Power Quality

Generation of harmonics should be limited to values prescribed by IEEE Standard 519 when measured at the interconnection point of ownership. Additionally, the FPL-NED transmission system should not be subjected to harmonic currents in excess of 5% of a transformer’s rated current as stated in ANSI/IEEE Standard C57.12.00.

III. L. End-User (Delivery Point) Metering

Unless mutually agreed otherwise, FPL-NED is to own, operate and maintain the metering installation equipment, including the instrument transformers, secondary conductors, cables, meters and transducers. If the interconnection facilities are owned by the end-user, and that party does not own the instrument transformers or meters, then a structure and a location for mounting metering transformers and recording devices are to be provided by the facility owner. End-user devices are not to be connected directly to potential or current transformer secondaries used for revenue metering.

III. M. End-User (Delivery Point) Auto-Restoration

End-user facilities are energized in the direction from FPL-NED to the load. Owners of interconnected load facilities are to become aware of ISO-NE policies and procedures regarding reenergization following an interruption. End-users with sensitive control systems or large motors should apply appropriate protection measures.

III. N. End-user (Delivery Point) Load Shedding Programs

Entities responsible for load serving delivery points shall implement and maintain an underfrequency load shedding program designed and coordinated with FPL-NED and in conformance with all applicable ISO-NE and NPCC policies, rules, procedures, standards and guidelines. FPL has the right to require entities responsible for load serving delivery points to implement an emergency load shedding program to the extent that such a program is required to assure transmission integrity under adverse conditions. The amount of load to be interrupted by emergency load shedding programs will be distributed and administered on a non-discriminatory basis.

III. O. End-user (Delivery Point) Generation

End-user customers wishing to install generating facilities to be operated in parallel with FPL-NED must notify FPL-NED in writing prior to the commencement of any work. The technical requirement for the connection of generation outlined in Section II of this document must be followed. No generation shall be operated in parallel with the FPL-NED transmission system without prior written approval of FPL-NED.

III. P. End-User (Delivery Point) Parallel Operation

The distribution and transmission facilities behind the designated delivery point with FPL-NED’s transmission system shall be operated as a radial system only. Operation in a mode which would tie two or more delivery points together in a manner which would cause the system behind the delivery points to be operated as a parallel network to the FPL-NED transmission system is prohibited without the express written permission of FPL-NED. The installation of such protective equipment may be required by FPL to ensure that parallel operation is automatically interrupted within the time frame allowed by FPL-NED’s standards.

APPENDIX 1

Generator Data Requirements

Appendix 1

Generator Data Requirements

It is recognized that some of the data listed in this Appendix may not be available prior to the start of an Interconnection Feasibility Study or a System Impact Study. Some of the data items are critical inputs to these studies and must be provided prior to the commencement of the Interconnection Feasibility Study. In addition to the data requirements specified herein, any additional information required pursuant to the ISO-NE Open Access Transmission Tariff or other ISO-NE rules and procedures shall be provided in accordance therewith.

Critical Data Items: A) all

B) 1, 2, 3, 4, 5, 7 & 8

D) 1, 2, 3 & 7

E) all

G) 1, 2, 3 & 4

H) all

I) 1, 2 & 4

J) 1, 3 & 6

K) all

L) 4 through 11

To the extent possible, all of the data listed in this Appendix should be provided as soon as it becomes available. All data items must be provided at least 60 days prior to commercial operation of the facility. FPL-NED may require additional data to complete the Interconnection Feasibility Study depending upon special study circumstances. Inaccuracies in some of the critical data items can influence study results to the extent that study conclusions are invalidated. FPL-NED reserves the right to require reapplication for the Interconnection Study in the event of data inaccuracies.

A) Contact Person - Provide name and address of person completing this form

1. Name:

2. Address:

3. City/State/Zip:

4. Telephone:

5. Date:

B) Project Location

1. County

2. Nearest Community

3. Township

4. Range

5. Section

6. Street Address

7. Project Location Map Please attach geographic map of project location

8. Planned In Service Date

C) Unit Identification

1. Plant Name and unit Number

2. Manufacturer

3. Generator Serial Number

4. Turbine Serial Number

D) Ratings and Capabilities

1. Total Plant Capability

a. Net Summer Continuous Capability MW

b. Net Winter Continuous Capability MW

c. Auxiliary Load MW

2. Number of Individual Generators

3. Nameplate kV Rating (nominal design voltage)

4. Generator Nameplate Rating MVA Rating @ Hydrogen Pressure

a.

b.

c.

d.

5. Rated Power Factor

6. Rated Speed

7. Rated Turbine Capability

a) Maximum

b) Summer continuous

c) Winter continuous _____________________

8. Field Voltage at Rated Load

9. Field Current at Rated Load

10. No-load Field Voltage at Generator Rated Voltage

11. Air Gap Field Voltage at Generator Rated Voltage

12. Field Resistance ohms (C

E) Inertia

1. WR2 for Generator and Exciter lb-ft2

2. WR2 for Turbine lb-ft2

3. Calculated H constant sec. @ MVA

F) Losses and Efficiency

1. Open circuit core loss kW

2. Windage loss kW

3. H2 seal and exciter friction loss kW

4. Stator I2R Loss at rated power and voltage (C kW

5. Rotor I2R Loss at rated power and voltage (C kW

6. Stray Load loss kW

7. Excitation losses kW

G) Generator Time Constants

1. T'do (Direct axis open circuit transient time constant) sec

2. T''do (Direct axis open circuit subtransient time constant) sec

3. T'qo (Quadrature axis open circuit transient time constant) sec

4. T''qo (Quadrature axis open circuit subtransient time constant) sec

5. Ta3 (Short circuit time constant) sec

H) Generator Impedances

1. MVA base for all impedance data MVA

2. kV base for all impedance data kV

Parameter Description p.u. value

3. Xd Direct axis synchronous reactance (unsaturated)

4. X'd Direct axis transient reactance (unsaturated)

5. X'dv Direct axis transient reactance (saturated)

6. X''d Direct axis subtransient reactance (unsaturated)

7. X''dv Direct axis subtransient reactance (saturated)

8. Xq Quadrature axis synchronous reactance (unsaturated)

9. X'q Quadrature axis transient reactance (unsaturated)

10. X''q Quadrature axis subtransient reactance (unsaturated)

11. XL Armature leakage reactance

12. X2v Negative sequence reactance (saturated)

13. X0v Zero sequence reactance (saturated)

14. R1 Positive sequence armature resistance at 75( C

15. R2 Negative sequence armature resistance at 75( C

16. R0 Zero sequence armature resistance at 75( C

17. Rdc Direct current armature resistance at 75( C

18. Generator neutral grounding resistance ohms

19. Generator neutral grounding reactance ohms

I) Required Characteristic Curves and Diagrams

1. Real and reactive power capability curves

2. Saturation curve, full load and no-load

3. "V" curves

4. One-Line diagram showing generator and substation equipment connections (i.e., switchyard configuration)

5. Relay one-line diagram

J) Excitation System Data

1. Excitation system type

2. Voltage regulator model name

3. Excitation system model, supply block diagram and model parameters in IEEE[4],[5] or PSS/E format

4. Voltage compensation, supply block diagram and settings if used

5. Voltage regulator over-excitation limiters, supply block diagram and model parameters in IEEE[6] format.

6. Power System Stabilizer (if used), supply Power System Stabilizer block diagram and model parameters in IEEE or PSS/E format.

7. Exciter saturation curve if a non static source is used for excitation power.

K) Turbine Governor Data

1. Model or equipment name for speed/load governor controls

2. Speed/Load governor model, supply block diagram and model parameters in IEEE[7],[8] or PSS/E format

L) Generator Step-up Transformer Data

1. Manufacturer

2. Model Type

3. Serial Number

3.

4. 4. Rating MVA

5. High voltage winding, nominal voltage kV

6. High voltage winding connection (wye/delta)

7. Low voltage winding, nominal voltage kV

8. Low voltage winding connection (wye/delta)

9. Transformer resistance p.u.

10. Transformer reactance p.u.

11. Transformer impedance base values MVA kV

12. Available tap settings

HV taps kV

LV taps kV

13. Expected tap settings

HV taps kV

LV taps kV

M) Start-up or Auxiliary Transformer Data

1. Manufacturer

2. Model Type

3. Serial Number

5.

6. 4. Rating MVA

5. High voltage winding, nominal voltage kV

6. High voltage winding connection (wye/delta)

7. Low voltage winding, nominal voltage kV

8. Low voltage winding connection (wye/delta)

9. Transformer resistance p.u.

10. Transformer reactance p.u.

11. Transformer impedance base values MVA kV

12. Available tap settings

HV taps kV

LV taps kV

13. Expected tap settings

HV taps kV

LV taps kV

14. Expected Startup Power Demand

MW

MVAR

Appendix 2

Procedures for Notification of Generating Plant

Operational Data and Control Status

Appendix 2

Procedures for Notification of Generating Plant

Operational Data and Control Status

Introduction

An essential part of operating a transmission system reliably is the coordination of reactive power sources to maintain an adequate transmission voltage profile both for normal and contingency conditions. Reactive sources must be distributed throughout electric systems due to the large voltage drops associated with transmission of reactive power. Operators of transmission systems follow voltage control strategies to minimize the risk of exceeding equipment voltage limitations and the transmission grid’s voltage stability limitations. Generators operating in parallel with the transmission system must operate with the automatic voltage regulator (“AVR”) on and follow the established voltage schedule for the voltage control strategy to be effective.

Owners of generators connected to the FPL-NED transmission system must coordinate with Transmission Operations to optimize generating plant transformer tap settings. By carefully selecting transformer tap ratios, it is possible to optimize generating plant voltages and reactive capabilities for the expected range of transmission voltages.

FPL-NED has established these information and notification procedures to facilitate the coordination of reactive power and to comply with the NERC Planning Standards. To the extent not specified in the ISO Open Access Transmission Tariff or other ISO-NE operating rules or procedures, the following procedures shall apply to all new generation interconnected to the FPL-NED transmission system.

To the extent there are any conflicts between the procedures or specifications contained in this Appendix 2 and the ISO-NE Open Access Transmission Tariff or other ISO-NE operating rules and procedures, the ISO-NE Tariff or rules and procedures shall govern.

Requirements

1. Notification of AVR status - All synchronous generators with MVA ratings larger than 20.0 MVA connected to the FPL-NED transmission system shall operate with the generator’s AVR on and in the voltage control mode to the extent practicable. The operator of the synchronous generator must contact the FPL-NED and ISO-NE when it becomes necessary to operate with the AVR off for more than 30 minutes and state the reason for operating with the AVR off. In addition to verbal notification of the reason for operating with the AVR off, the AVR status should also be automatically telemetered to ISO-NE control center or its designated satellite, as appropriate.

Owners of generating equipment are responsible for maintaining records that a) provide a summary of the number of hours per month each generator was not in the automatic voltage control mode while operating in parallel with the FPL-NED transmission system and b) provide the date, duration, and reason for each period of occurrence to FPL-NED and ISO-NE Control Center on its satellite, as applicable. These records must be available for the preceding 12 months and must be provided within five business days of request.

2. Notification of Deviation from Voltage Schedule - All synchronous generators connected to the FPL-NED transmission system with ratings larger than 20.0 MVA shall maintain a voltage schedule at the point of interconnection as prescribed by the ISO-NE to the extent allowed by the capabilities and limitations of the generating plant equipment.

ISO-NE will advise generating plant operators of its current voltage schedule. This voltage schedule may change on an hourly basis depending on conditions in the power system.

The operator of the synchronous generator must contact ISO-NE system operator when the generator can not maintain the voltage at the point of interconnection as prescribed by the ISO-NE for more than 30 minutes. The operator of the synchronous generator shall state the reason for deviating from the voltage schedule and provide the ISO-NE system operator with the generator’s reactive limitations that exist at that time. Owners of generating equipment are responsible for maintaining records that a) provide a summary of the number of hours per month each generator was not following the voltage schedule as prescribed by the ISO-NE system operator and b) provide the date, duration, and reason for each period of occurrence. These records must be available for the preceding 12 months and must be provided within five business days of a request.

3. Notification of Plant Capabilities - Prior to commercial operation, the generating equipment owner shall notify the ISO-NE system operator of the expected generator capabilities as listed below.

Summer Continuous Generator Gross Capabilities

Generator MW Lagging MVAR Leading MVAR

_________ ___________ ___________

Winter Continuous Generator Gross Capabilities

Generator MW Lagging MVAR Leading MVAR

_________ ___________ ___________

Total Plant Auxiliary MW MVAR

Power Usage

Summer ________ _________

Winter _________________

Updated information based on actual test results shall be provided to the ISO-NE System Operator or its designate satellite as it becomes available.

4. Notification of Turbine Governor Status - Owners of synchronous generators with ratings larger than 20.0 MVA connected to the FPL-NED transmission system shall notify the ISO-NE system operator of changes in the status of the speed/load governing controls for the turbine. The ISO-NE system operator or its designate satellite shall be made aware of nonfunctioning, partially functioning or blocked governor controls when these conditions are expected to persist for five days or more.

5. Notification of Available Transformer Ratios and Changes in Transformer Data – Owners of synchronous generators with ratings larger than 20.0 MVA connected to the FPL-NED transmission system shall provide the ISO-NE system operator or its designate satellite with the transformer data as specified in FPL-NED’s Facility Connection Requirements document (Appendix 1, Sections L and M). Updated information shall be provided when transformer changes are made. The generator equipment owner will make transmission ratio changes as prescribed by ISO-NE policies and standards. As required by the NERC Planning Standards in Compliance Template III.C. S2 M6, the generating equipment owners are expected to make transformer tap changes during the next scheduled maintenance period, unless otherwise determined by ISO-NE.

6. Notification of Generator AVR Control and Protection Settings – Most synchronous generator AVRs are equipped with limiting controls that help protect the generator while also allowing the generator to support the grid during temporary excursions in transmission voltage. These limiting controls must be properly coordinated with generator protection and with the generator’s short term voltage/reactive capabilities. Two common examples of these controls are the maximum excitation limiter (coordinates with overexcitation protection) and the minimum excitation limiter (coordinates with the loss of field relay).

Prior to commercial operation, the owner of a synchronous generator with a rating larger than 20.0 MVA shall provide FPL-NED and the ISO-NE system operator with documentation that describes the functional operation and settings for the AVR’s control functions. This documentation shall demonstrate the AVR’s controls are coordinated with the generator protection and with the generator’s short term capabilities. In cases where the AVR has been set to regulate a voltage other than the generator’s terminal voltage or it has been set to regulate a compensated terminal voltage, sufficient data shall be provided to allow the AVR to be modeled accurately.

7. Provision of Generator Test Data – One of the standard generator commissioning tests is to introduce a step change in the AVR’s reference voltage with the generator running at synchronous speed but not connected to the transmission system. This is referred to the open circuit, step in voltage test and is used to confirm the AVR is functioning properly.

Prior to commercial operation, the owner of a synchronous generator with a rating larger than 20.0 MVA shall provide FPL-NED and the ISO-NE system operator with open circuit, step in voltage test results. Recordings of the generator terminal voltage and generator field voltage magnitudes must be provided together with any calibration data necessary to equate the recordings with actual voltages. In situations where it is impractical to measure the generator field voltage (e.g. brushless excitation systems) alternate quantities with equivalent response characteristics can be provided. An estimate of the generator’s field winding temperature during this test must be provided.

Revisions made to Facility Connection Requirements

Original Issued 5/1/2005

Added Section I.T (Coordination of Impact Assessments) 5/31/2007

-----------------------

[1] NERC Planning Standards, Table 1

[2] Items G1, G2, G3, and G4 are requirements of NERC Planning Standards, section III. C.

[3] Sections H1, H2, H3, and H4 are required by NERC Planning Standards, section II. B.

[4] IEEE Standard 421.5-1992 "IEEE Recommended Practice for Excitation System Models for Power System Stability Studies"

[5] IEEE Digital Excitation Task Force, "Computer Models for Representation of Digital-Based Excitation Systems," IEEE Transactions on Energy Conversion, Vol. 11, No. 3, September 1996

[6] IEEE Committee Report, "Recommended Models for Overexcitation Limiting Devices," IEEE Transactions on Energy Conversion, Vol. 10, No. 4, December 1995

[7] IEEE Committee Report, "Dynamic Models for Steam and Hydro Turbine Control Models for System Dynamic Studies," IEEE transactions on Power Apparatus and Systems, Vol. PAS-92, November, 1973

[8] W.I. Rowen, "simplified Mathematical Representations of Heavy Duty Gas Turbines," Transactions of ASME, Vol.105(1), 1983

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